System And Method For Communicating Data Between Wellbore Instruments And Surface Devices

ABSTRACT

A method for synchronizing an actuation of a seismic source with at least one of an acquisition and storage of an acoustic wave by a seismic tool having steps of determining at least one of a drilling pause and a seismic measurement, transmitting a trigger signal to a tool controller, actuating the seismic source; receiving the trigger signal and recording seismic waves in a data storage medium.

FIELD OF THE INVENTION

Aspects relate to communication between a seismic source and a seismictool positioned within a wellbore. More specifically, non-limitingaspects relate to a system and method for communicating data betweenwellbore instruments and surface devices.

BACKGROUND INFORMATION

Logging while drilling (“LWD”) while drilling operations may beperformed using one or more remote signal sources and one or more signalreceiver modules disposed on a drill string. Examples ofsources/receivers include acoustic, and electro-magneticsources/receivers, for example similar to those used in seismic whiledrilling, controlled sources electromagnetics (“CSEM”), and/or wellboreelectro-magnetic imaging (deep resistivity imaging) as well as seismicwhile drilling (“SWD”) operations.

Currently, conventional systems have significant difficulty in timingbetween transmitting seismic signals and receiving those seismicsignals. Such difficulty results in excessive recording times, loss ofpower of critical components from inefficient use and excessive analysistime for evaluation.

SUMMARY

Aspects presented provide a capability to record seismic signals withoutthe defects of conventional systems. A seismic while drilling tool (“SWDtool”) may be incorporated or positioned in a drill string and conveyeddownhole into a wellbore. The SWD tool typically includes at least oneacoustic sensor used to measure acoustic waves that have been generatedby at least one remote seismic source (for example an air-gun locatednear the Ocean's surface), and that have travelled through the Oceanand/or Earth formations.

The SWD tool may record the acoustic signals sensed during timeintervals in the tool memory. During some recorded time intervals, noacoustic wave generated by the remote seismic source may possibly reachthe acoustic sensor of the SWD tool. For example, this may occur becausethe remote seismic source may not have recently been actuated. As aresult, the tool memory stores data for time intervals where a seismicsource has not even generated an acoustic wave.

In one example embodiment, a method for synchronizing an actuation of aseismic source with at least one of an acquisition and storage of anacoustic wave by a seismic tool is presented, comprising determining atleast one of a drilling pause and a seismic measurement, transmitting atrigger signal to a tool controller, actuating the seismic source,receiving the trigger signal; and recording seismic waves in a datastorage medium.

In another example embodiment, a configuration for synchronizing anactuation of a seismic source with at least one of an acquisition andstorage of an acoustic wave by the seismic tool, comprising: a datastorage medium; a seismic source configured to produce acoustic signals;and an acoustic receiver configured to receive the acoustic signals. Theconfiguration may also provide a rig controller configured to receivemeasurements from rig operations and transmit a trigger signal and atool controller configured to receive the trigger signals and initiaterecording in the data storage medium.

In another example embodiment, a method for synchronizing an actuationof a seismic source with at least one of an acquisition and storage ofan acoustic wave by a seismic tool comprising: determining at least oneof a drilling pause, transmitting a trigger signal to the seismicsource, recording seismic waves in a data storage medium, receiving thetrigger signal; and actuating the seismic source.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 shows an example of a well site having a seismic source and aseismic tool in an embodiment of the disclosure.

FIG. 2 shows a schematic of communication between a seismic source and aseismic tool in an embodiment of the disclosure.

FIG. 3 illustrates a flow chart related to a method of triggering aseismic source in an embodiment of the disclosure.

FIG. 4 illustrate a flow chart related to another method of triggering aseismic source in an embodiment of the disclosure.

DETAILED DESCRIPTION

The disclosure provides a system and a method that may eliminate or atleast reduce the number of recorded time intervals during which noacoustic wave was generated by the seismic source or could possiblyreach the acoustic sensor of the SWD tool. Such systems and methods curethe defects of systems not configured to efficiently record acousticwaves. These systems allow for increased capabilities as well asfinancial gains for operators. Aspects of the system and methodsprovided may ensure that the time intervals during which an acousticwave has been generated by the remote seismic source has reached theacoustic sensor are recorded, thus reducing error in the entire systemand recording of seismic wave. In addition, the system and method mayreduce the duration of the recorded time intervals during which anacoustic wave generated by the remote seismic source has reached theacoustic sensor.

FIG. 1 shows a schematic of one example of a well site 100, which may belocated onshore or offshore. The well site 100 illustrated in FIG. 1 islocated offshore on a drilling vessel 10. The drilling vessel 10 has adrill rig 20 on it that is used to drill a well 50 in Earth's formationswith a drill string 30. The drill string 30 may be assembled bythreadedly coupling together end to end a number of segments (“joints”)22 of drill pipe. The drill string 30 may include a drill bit 12 at itslower end. Casing 13 and/or a blow out preventer 8 may be positioned inthe well 50 as shown in FIG. 1. The drill string 30 may be composed ofconventional drill pipe or may be wired drill pipe or coiled tubing, asnecessary and as non-limiting embodiments. When the drill bit 12 isaxially urged into the formations F at the bottom of the wellbore 50 andwhen it is rotated by equipment (e.g., top drive or rotary table) on thedrilling rig 20, such urging and rotation causes the drill bit 12 toaxially extend the well 50. The drill string 30 in the present examplemay be a so-called “wired” drill pipe that has associated with each pipejoint a cable, such as an electrical and/or optical conductor (not shownin FIG. 1) for communicating electrical power and signals from wellboreinstruments 14 to the surface. The cable is typically communicativelycoupled at each end of each joint 22, such as by use of an inductive orflux coupler. Non-limiting examples of such wired, threadedly coupleddrill pipe are described in U.S. Patent Application Publication No.2006/0225926 filed by Madhavan et al., the underlying patent applicationfor which is assigned to the assignee of the present invention. Anotherexample of wired drill pipe is described in U.S. Pat. No. 6,641,434issued to Boyle et al. and assigned to the assignee of the presentinvention. Such drill pipe structures are only provided as examples andare not intended to limit the scope of the present disclosure.

The wellbore instruments 14 may be in communication with a logging unit70, which may be positioned at the Earth's surface, as a non-limitingembodiment. The logging unit 70 may transmit and may receive signals toand from the wellbore instruments 14 via a telemetry system, such as mudpulse telemetry, electromagnetic telemetry, acoustic telemetry, wirelinetelemetry and/or wired drill pipe telemetry (previously discussed). Thelogging unit may record data obtained from the wellbore instruments 14.The wellbore instruments 14 may be any tool, sensor, or device capableof obtaining data related to the formation F, the well 50 and/or thedrill string 30. The wellbore instruments 14 may obtain a measurement orsample of the formation F or the well 50. In one non-limitingembodiment, the wellbore instruments 14 may be logging while drilling(“LWD”) instruments or measurement while drill (“MWD”) instruments. Asdefined, the formation F is a geological formation or set of geologicalformations which is desired to be evaluated. In embodiments, thewellbore instruments 14 may be one or more devices that measureformation characteristics: a resistivity measuring device; a directionalresistivity measuring device; a sonic measuring device; a nuclearmeasuring device; a nuclear magnetic resonance measuring device; apressure measuring device; a seismic measuring device; an imagingdevice; a formation sampling device; a natural gamma ray device; adensity and photoelectric index device; a neutron porosity device; and aborehole caliper device. In embodiments, the wellbore instruments 14 maybe one or more devices for measuring characteristics of the drill string30 and/or may include one or more of the following types of measuringdevices: a weight-on-bit measuring device; a torque measuring device; avibration measuring device; a shock measuring device; a stick slipmeasuring device; a direction measuring device; an inclination measuringdevice; a natural gamma ray device; a directional survey device; a toolface device; a borehole pressure device; and a temperature device. Thewellbore instrument 14 may be a wireline configurable tool which may bea tool commonly conveyed by wireline cable as known to one havingordinary skill in the art. For example, the wireline configurable toolmay be a tool for obtaining a sample of the formation F, such as acoring tool, a sampling tool, a fluid analyzing tool, and/or a tool formeasuring characteristics of the formation F, such as gamma radiationmeasurements, nuclear measurements, density measurements, and porositymeasurements. For the drill string components disclosed, power may beprovided to the components through use of batteries or by use of a fluidturbine, as a non-limiting embodiment.

In an embodiment, the wellbore instruments 14 include at least oneseismic tool 60 that may include a seismic receiver, a seismic source,and/or memory for storing information or data related to the generationor receipt of a seismic wave. It should also be noted that more than oneseismic tool 60 may be positioned within the wellbore instruments 14. Inaddition, one or more of the seismic tools 60 may be positioned alongthe drill string 30, such as at distinct distance from the rig 20 and/orthe Earth's surface. For example, a plurality of seismic tools 60 may bedisposed along the drill string 30 and be communicatively coupled at anyposition along the wired drill pipe string.

The drilling rig 20 may have or may be in communication with a seismicsource 40. The seismic source 40 may be provided in another vessellocated remote from the drilling vessel 10 and/or located downholewithin the well 50. The seismic source 40 may be actuated to generateacoustic waves that travel through the formations F, for example throughthe ocean and through the Earth's formations. While a “surface” sourceis shown in FIG. 1, the source may alternatively or additionally be a“downhole” source conveyed in the wellbore via the drill string, forexample, a source of type similar to the source described in U.S. Pat.No. 6,782,970.

The seismic tool 60 may sense, record, and process acoustic wavesgenerated by the seismic source 40. For example, the seismic tool 60 mayutilize a seismic/acoustic receiver to receive the acoustic wave, aprocessor to analyze the received acoustic wave, and a memory to storedata related to the processed or unprocessed acoustic wave. The seismictool 60 may transmit data indicative of the recorded acoustic wave, suchas filtered/decimated recorded waves. The data indicative of therecorded acoustic waves may be used to control the trajectory of thewell, and/or determine pore pressure, among other uses. It should beappreciated by those having ordinary skill in the art that while FIG. 1shows one seismic tool 60 and one seismic source 40, a plurality of theseismic tools 60 and/or a plurality of seismic sources 40 may also beused.

FIG. 2 illustrates a schematic 120 of one example implementation of theinvention. In the schematic 120, the seismic source is in communicationwith the seismic tool via a telemetry system 200, which may comprise oneor more of the above telemetry systems, such as wired drill pipe. Theseismic tool 60 may include a data storage medium 23 and/or an acousticreceiver 25. The data storage medium 23 may be any device or componentcapable of storing data, such as flash memory, a database, read onlymemory. The acoustic receiver 25 may include one or more hydrophones,geophones or other devices capable of receiving and/or deciphering anacoustic wave. It should be understood that the acoustic receiver andthe data storage medium 23 may be incorporated into the seismic tool 60,such as internal to the seismic tool 60, or may be external to theseismic tool 60 and in communication. The seismic tool 60 may have aninternal clock and/or may be in communication with a clock to have aprecise and accurate time with respect to a surface clock.

A tool controller 27 may be incorporated into and/or in communicationwith seismic tool 60. The tool controller 27 may be in communicationwith the seismic source 40 via the telemetry system 200 and/or a rigcontroller 41. The rig controller 41 may be communicatively coupled tothe acoustic source 40. When instructed to, the tool controller 27acquires waveforms (a waveform may be an acoustic wave signal) from theacoustic receiver 25. The seismic tool may store the acquired acousticwave in the data storage medium 23.

The rig controller 41 may be incorporated in or in communication withthe logging unit 70. The rig controller 41 may be in communication withthe acoustic source 40 to activate the seismic source 40. The seismicsource 40 may be any device capable of generating acoustic waves throughthe Earth, such as an air gun, an explosive, for example dynamite, aplasma sound source, or a seismic vibrator. The rig controller 41 mayreceive a command signal from the tool controller 27 to activate theseismic source 40. The tool controller 27 may send a command signal tothe rig controller 41 to activate the seismic source 40.

In an embodiment, both uphole and downhole components are coupled with afast telemetry system, for example a telemetry system with low latencyand/large bandwidth, such as wired drill pipe telemetry. Operationscontrolled by the rig controller 41 and operations controlled by thetool controller 27 may be synchronized.

The arrangements disclosed may be used in conventional verticalwellbores, deviated wellbores and in extended reach systems asnon-limiting embodiments. Geological conditions may vary along the pathstraversed by the seismic waves allowing the operator to accuratelyrecord signals.

FIG. 3 illustrates a flow chart 300 of a method of actuating the seismicsource 40 with the seismic tool 60. For example, synchronizing theactuation of acquisition and storage of the acoustic waves generated bythe seismic source 40 and measured with the acoustic receiver (orsensor) 25 of the seismic tool 60.

As provided in step 302, a drilling and/or tripping pause is detected.For example, the tool controller 27 may determine that drilling hasmomentarily paused and that a seismic measurement may be performed. U.S.Pat. No. 6,237,404 describes at least one example of how this may beaccomplished. In another example, the drilling and/or tripping pause maybe detected by the logging unit 70 and/or one of the wellboreinstruments 14, such as the seismic tool 60. The drilling and/ortripping pause may also be manually detected, such as by an operator. Insuch an instance, a command may be input and/or transmitted to thelogging unit 70 and/or the seismic tool 60.

As shown at step 304, a trigger signal may be transmitted. For example,the tool controller 27 may transmit a trigger signal to the rigcontroller 41, such as by use of the telemetry system. Instead or inaddition to, the rig controller 41 may transmit the trigger signal tothe tool controller 27.

Recording of the acoustic wave may be initiated as shown at step 306. Inthis step, the recording in the data storage medium 23 of the acousticwave measured by the acoustic receiver 25 is initiated. For example, itcan be initiated shortly after step 304 is performed, or after apredetermined time or duration stored or transmitted to the seismic tool60 as a configuration parameter.

At step 308, as shown in FIG. 3, the rig controller 41 may receive thetrigger signal transmitted by the tool controller 27. Of course, thetool controller 27 may receive a signal that triggering of the seismicsource 40 has or is about to occur, such as from the seismic source 40,the logging unit 70 and/or the rig controller 41.

The rig controller 41 may actuate the seismic source 40 upon receivingthe trigger signal as shown at step 310. The rig controller 41 may haveinstructions to await a predetermined about of time after receiving thetrigger signal to actuate the seismic source 40. The trigger signal mayrequest that the seismic source 40 be actuated at a predetermined time.

The recording of the acoustic wave by the seismic tool 60 may beterminated at step 312. For example, the tool controller 27 mayterminate the recording of the acoustic wave after a predetermined timeafter sending the trigger signal to the rig controller 41. The toolcontroller 27 may terminate recording upon receipt of a signal from therig controller 41 and/or the logging unit 70.

It is apparent, in at least an embodiment, that by applying this method,the seismic source 40 may be systematically fired each time the toolcontroller 27 initiates the recording a waveform. In addition, theinitiation of recording and the firing can be synchronized. Of course,to achieve this, the telemetry system should provide sufficiently fast(or repeatable) communication of the trigger signal.

The acoustic waveform obtained by the acoustic receiver 25 may beprocessed as shown at step 314. The acoustic waveform may be processeddownhole by the seismic tool 60 and/or processed at the surface at thelogging unit 70. In addition, a portion of the stored waveform havingsignals of interest may be determined. The processed waveform or aportion of the waveform may be transmitted to the logging unit 70 and/orthe rig controller 41, as shown at step 316.

The processed waveform may be utilized for any reason known to thosehaving ordinary skill in the art as shown at step 318. For example, theprocessed waveform may be used to adjust a time-depth conversion on aseismic map, to make a drilling decision, or to make a productiondecision.

FIG. 4 illustrates a flow chart 400 of an alternate method ofsynchronizing the actuation of the seismic source 40 with theacquisition and storage of the acoustic wave by the seismic tool 60.Determination of a drilling pause and/or that a seismic measurement isdesired may occur at step 402. For example, the rig controller 41, a“master” controller disposed at the Earth's surface, such as the loggingunit 70, or the seismic tool 60 may identify the drilling pause or thedesire for a seismic measurement. The rig controller 41 may receivemeasurement from draw-works, mud pumps, top drives, from an inputinterface (a keyboard) with a surface operator, or from another sourceas will be appreciated by those having ordinary skill in the art. Thesemeasurements or inputs may be used to determine the drilling pauseand/or the desire for a seismic measurement.

A trigger signal may be transmitted to the seismic source 40 as shown atstep 404. For example, the rig controller 41 may transmit a triggersignal to the tool controller 27. Another device at the surface or incommunication with the seismic source 40 may transmit the triggersignal, such as via the logging unit 70. The rig controller 41 mayactuate the seismic source 40 as shown at step 406. As an example, therig controller 41 may actuate the seismic source a predetermined amountof time after transmitting the trigger signal. The tool controller 27may receive the trigger signal as shown at step 408.

The tool controller 27 may initiate the recording seismic waves in thedata storage medium 23 as shown at step 410. The recording may beinitiated immediately after receiving the trigger signal, after apredetermined amount of time, and/or at a certain time. The seismic tool60 may terminate the recording of the seismic waves at a predeterminedtime, after a predetermined duration and/or upon receipt of a signalfrom the rig controller 41 or logging unit 70. The seismic wavesobtained may be processed, transmitted to the logging unit 70 and/orused for drilling, production or well service decisions as previouslydescribed.

In one example embodiment, a method for synchronizing an actuation of aseismic source with at least one of an acquisition and storage of anacoustic wave by a seismic tool is presented. The method may comprisedetermining at least one of a drilling pause and a seismic measurement;transmitting a trigger signal to a tool controller; actuating theseismic source; receiving the trigger signal; and recording seismicwaves in a data storage medium.

In another example embodiment, the method may be accomplished whereinthe actuating the seismic source is accomplished through a rigcontroller.

In another example embodiment, the method may be accomplished whereinthe actuating the seismic source is accomplished by the rig controllerthat actuates the seismic source a predetermined amount of time aftertransmitting the trigger signal.

In another example embodiment, the method may be accomplished whereinthe actuating the seismic source is accomplished a predetermined amountof time after transmitting the trigger signal.

In another example embodiment, the method may be accomplished whereinthe receiving the trigger signal is by a tool controller.

In another example embodiment, the method may be accomplished whereinthe initiating the recording of the seismic waves is accomplished by thetool controller.

In another example embodiment, the method may be accomplished whereinthe recording the seismic waves in the data storage medium occurs one ofimmediately after receiving the trigger signal, after a predeterminedamount of time, and at a specified time.

In another example embodiment, a configuration for synchronizing anactuation of a seismic source with at least one of an acquisition andstorage of an acoustic wave by the seismic tool is presented comprising:a data storage medium; a seismic source configured to produce acousticsignals; an acoustic receiver configured to receive the acousticsignals; a rig controller configured to receive measurements from rigoperations and transmit a trigger signal; and a tool controllerconfigured to receive the trigger signals and initiate recording in thedata storage medium.

In another example embodiment, a method for synchronizing an actuationof a seismic source with at least one of an acquisition and storage ofan acoustic wave by a seismic tool comprising: determining at least oneof a drilling pause; transmitting a trigger signal to the seismicsource; recording seismic waves in a data storage medium; receiving thetrigger signal; and actuating the seismic source.

In another example, the method may further comprise terminating therecoding of the seismic waves in the data storage medium.

While the invention has been described with respect to a limited numberof embodiments, those skilled in the art, having benefit of thisdisclosure, will appreciate that other embodiments can be devised whichdo not depart from the scope of the invention as disclosed herein.Accordingly, the scope of the invention should be limited only by theattached claims.

What is claimed is:
 1. A method for synchronizing an actuation of aseismic source with at least one of an acquisition and storage of anacoustic wave by a seismic tool comprising: determining at least one ofa drilling pause and a seismic measurement; transmitting a triggersignal to a tool controller; actuating the seismic source; receiving thetrigger signal; and recording seismic waves in a data storage medium. 2.The method according to claim 1, wherein the actuating the seismicsource is accomplished through a rig controller.
 3. The method accordingto claim 2, wherein the actuating the seismic source is accomplished bythe rig controller that actuates the seismic source a predeterminedamount of time after transmitting the trigger signal.
 4. The methodaccording to claim 1, wherein the actuating the seismic source isaccomplished a predetermined amount of time after transmitting thetrigger signal.
 5. The method according to claim 1, wherein thereceiving the trigger signal is by a tool controller.
 6. The methodaccording to claim 1, wherein the initiating the recording of theseismic waves is accomplished by the tool controller.
 7. The methodaccording to claim 1, wherein the recording the seismic waves in thedata storage medium occurs one of immediately after receiving thetrigger signal, after a predetermined amount of time, and at a specifiedtime.
 8. A configuration for synchronizing an actuation of a seismicsource with at least one of an acquisition and storage of an acousticwave by a seismic tool, comprising: a data storage medium; a seismicsource configured to produce acoustic signals; an acoustic receiverconfigured to receive the acoustic signals; a rig controller configuredto receive measurements from rig operations and transmit a triggersignal; and a tool controller configured to receive the trigger signalsand initiate recording in the data storage medium.
 9. A method forsynchronizing an actuation of a seismic source with at least one of anacquisition and storage of an acoustic wave by a seismic toolcomprising: determining at least one of a drilling pause; transmitting atrigger signal to the seismic source; recording seismic waves in a datastorage medium; receiving the trigger signal; and actuating the seismicsource.
 10. The method according to claim 9, further comprising:terminating the recoding of the seismic waves in the data storagemedium.